Baker Hughes, a Ge Compnay, LLC

Baker Hughes Corporation

Baker Hughes Oilfield Operations LLC

Baker Hughes Holdings LLC

Naima Bestaoui-Spurr

Qi Qu

Sumit Bhaduri

Terry D Monroe

Hoang Van Le

Kimberly Spurlock Lant

James B Crews

D V Satyanarayana Gupta

Mark Alan Vorderbruggen

Harold Dean Brannon

Brian Benedict Beall

Harold Gene Hudson

Radhika Suresh

Christopher John Stephenson

Kimberly Spurlock-Lant

Stephanie A Weiss

Tianping Huang

Scott Gregory Nelson

Robert S Hurt

Frances H DeBenedictis

Ahmed M Gomaa

Robert E Comer

Marty J Usie

Hanh Nguyen

Hyunil Jo

Julio R Gomez

Ahmed Shehata

Farid Bernardo Cortes Correa

Camilo Andres Franco Ariza

Samira Heidari

Mohamed Dawara

Francis H DeBenedictis

Robert Samuel Hurt

Brian B Beall

A method of imparting hydrophobicity and/or oleophobicity to a surface of a subterranean formation penetrated by a well during production of hydrocarbons from the well consists of pumping a surface modifying wettability agent into the well, the surface modifying wettability agent having an anchor, one or more hydrophobic and/or oleophobic functional groups attached to the anchor and one or more alkoxy groups as blocking moieties which increase stability of the agent in the presence of water by slowing down hydrolysis at the formation surface.

Method of altering the wettability of a subterranean surface to enhance protection of hydrocarbons

Method of altering the wettability of a subterranean surface to enhance production of hydrocarbons

Oil-soluble well treatment agents may be slowly released into a well or a subterranean formation by use of an aqueous fluid of (i) an oil-in-water dispersion having the oil-soluble well treatment agent as a dispersed phase and (ii) a second component having an oil-soluble or water-soluble primer coated onto a portion of its surface. The amount of the oil-soluble well treatment agent in the oil-in-water dispersion is from 20 to 50 weight percent and the average particle size of the oil-soluble well treatment agent in the dispersion may be from 0.005 to 2 micrometers. The oil-in-water dispersion may further contain a water-soluble well treatment agent.

Method of introducing oil-soluble well treatment agent into a well or subterranean formation

An aqueous fluid is gelled in a productive zone of a subterranean formation to create a temporary fluid-impermeable barrier. The fluid contains nanoparticles, a polyacrylamide having a weight average molecular weight from about 1.5 million to 22 million Dalton and an encapsulated liquid crosslinking agent. Upon release of the liquid crosslinking agent, the barrier is formed by crosslinking the polyacrylamide. The nanoparticles remain dispersed in the crosslinked gel. The fluid-impermeable barrier is effective over a period of at least 1 hour up to 2 weeks while the downhole temperature in the well is at least 300° C.

Temporary isolation system for reservoirs

The strength of a proppant or sand control particulate may be improved by coating the proppant to form a composite. The composite has enhanced compressive strength between about 34 to about 130 MPa and minimizes the spalling of fines at closure stresses in excess of 5,000 psi. Conductivity of the proppant pack in the fractures is further enhanced due to the increase in strength of the particles.

Method of treating subterranean formations with composites having enhanced strength

A composite for controlling the release of a well treatment agent or for inhibiting or preventing the formation of contaminants into a fluid or a surface within a reservoir contains a well treatment agent immobilized on a surface of the support or into the pores of a porous support. The composite is at least partially coated with an organic polymer or inorganic material. The composite exhibits sufficient strength for the composite to be used as a proppant or in conjunction with a proppant.

Method of using coated composites containing delayed release agent in a well treatment operation

Fouling caused by contaminants onto a metallic tubular, flow conduit or vessel in an underground reservoir or extending from or to an underground reservoir may be inhibited by applying onto the surface of the metallic tubular, flow conduit or vessel a treatment agent comprising a hydrophobic tail and an anchor. The anchor attaches the treatment agent onto the surface of the metallic tubular, flow conduit or vessel.

Method of inhibiting deposition of contaminants onto a metallic surface with a surface modifying treatment agent

A well treatment fluid contains a surface modifying treatment agent having an anchor and a hydrophobic tail. The surface modifying treatment agent is an organophosphorus acid derivative. After the well treatment fluid is pumped into a well penetrating the subterranean formation, the anchor binds to the surface of the formation. The subterranean formation is a siliceous formation or a metal oxide-containing subterranean formation. The anchor bonds to a Si atom when the formation is a siliceous formation and to the metal of the metal oxide when the formation is a metal oxide-containing formation. After being bound to the surface of the formation, frictional drag within the well is reduced. This allows for faster recovery of formation fluids. The bonding of the surface modifying treatment agent onto the formation may further be enhanced by first pre-treating the formation with a non-aqueous fluid. By increasing the number of sites for the surface modifying treatment agent to bind onto the surface of the subterranean formation, productivity is improved.

Method of using surface modifying treatment agents to treat subterranean formations

A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor is an organophosphorus acid derivative. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate.

Organophosphorus containing composites for use in well treatment operations

Relatively low strength and/or relatively low density, but ductile materials may be folded or crumpled and finely divided to give proppants for introduction into hydraulic fractures, where the folded or crumpled structure of the proppants gives relatively increased strength relative to the relatively low strength and/or relatively low density of the materials. Materials not previously considered suitable for proppants may be considered when structure or configured in this manner. Similarly to the case where crumpled paper within a cardboard box keeps it from collapsing, the folded or crumpled material spontaneously develops structural rigidity at relatively low volume fractions without a specific externally imposed design. The folded or crumpled proppants may also be used alone or together with conventional proppants for sand control in gravel packs or frac packs.

Folded or crumpled proppants with increased material strength for hydraulic fracturing, gravel packing and frac packing

Improving the knowledge about how hydraulic fracture networks are generated in subsurface shale volumes in unconventional wellbores may be accomplished with various configurations of at least one diagnostic lateral wellbore using at least one diagnostic device disposed in the diagnostic lateral wellbore. By extending diagnostic lateral wellbores from adjacent lateral wellbores and/or separately drilling diagnostic lateral wellbores, and analyzing signals received by diagnostic devices placed in the diagnostic lateral wellbores, knowledge about fracture networks, the parameters that control fracture geometry and reservoir production and how reservoirs react to refracturing techniques may be greatly improved. Additionally, such diagnostic lateral wellbores can provide quicker location of sweet-spot horizons in reservoirs.

Diagnostic lateral wellbores and methods of use

Method of inhibiting fouling on a metallic surface using a surface modifying treatment agent

Cements, such as alkali activated binder, may be used as coatings on proppants, such as sand, to improve the strength thereof. The resulting chemically bonded phosphate ceramic (CBPC) coated proppants show increased compressive strength between about 60 to about 130 MPa, as well as produced fines of lower than about 10 wt % at 10,000 psi closure stress.

Proppants with improved strength

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Method of enhancing fracture complexity using far-field divert systems

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The Woodlands, TX, United States of America

Naima Bestaoui-Spurr